Projects

  • Portable Fuel Lab

    Portable Fuel Lab

    Complete Portable Fuel Testing

    Fuel Lab in One Box

    Gasoline, Diesel, Naphtha, Fuel Oil, Lubricant Oil, Biodiesel, Crude Oil Analysis

    Grenergy presents full spectrum of all important fuel identification and analysis parameters in one single unit. All type of fuels, crude oil and lubricants can be analyzed using same unit.

    Fueld Lab Unit is simply combination of seven devices;

    1.FTIR Analyzer
    2.Titration Analyzer
    3.Viscometer
    4.Flash Point Analyzer (Open Cup and Closed Cup)
    5.Cold Flow Analyzer
    6.Sulfur Analyzer
    7.Metal Analyzer
     

    Complete Portable Fuel Testing

    Major Parameters which can be measured  are as  follows;

    1.Flash Point (Open Cup)
    2.Density, API and Specific Gravity
    3.Kinematic Viscosity
    4.TAN (Total Acid Number), TBN (Total Base Number)
    5.Pour Point, CFPP, Gel Point
    6. Sulfur
    7.Metals (From Na until Uranium heavy and light metals)
    8.Distillation
    9.Components, (Olefins, Parafins, Aromatics, Poly nuclear aromatics, Oxygenates, FEMA, etc.)
    10.Octane Number (RON, MON)
    11.Cetane Number and Cetane Index
    12.Water Content, particle content
     

    FLUID CHEMISTRY: Tests for TAN/TBN, water content, soot, oxidation,

    VISCOSITY: Series kinematic viscometer @40°C (cSt); solvent-free; low sample volume

    Oxidation, Nitration, Sulfation, Soot, Glycol/Antifreeze, Waterw FAME, Glycerin
    Fuel Dilution in Hydraulic Fluids

    Which combines the advantages of mid-FTIR and near-FTIR spectroscopy for utmost measurement accuracy.

    More than 70 fuel parameters are accurately determined by scanning the complete spectrum with superior resolution.

    Works with only 7 ml sample without any sample preparation.

    It analysis density, components, distillation properties of the fuel sample.

    Almost all physical parameters can be estimated using these information.

    No Need for Expert to use.

    Multiple Interface Software and Remote Reporting

    Full technical support 24/7

    2 years of warranty

    Scope of supply: 

    Filling tubes with connectors

    piston oil

    syringe

    glass syringe for filling

    disposal container with lid

    outlet tube

    inlet filter assembly

    power supply cable

    USB device

    instruction manual and test certificate 

    More
  • Modular Refinery

    Modular Refinery

     

    SYSTEM COMPONENTS

    Modular Microrefinaryis based on combination of latest revolutionary technologies
    •Hybrid Distillation with proprietary catalysts
    •Super Critical Extraction
    •Gassification& Catalytic Reforming
    Hybrid high capacity economic scalable distillation
    Combination

     

    Combination of state of the art technologies Online, onsite refining at wellhead

    Hybrid Catalytic Distillation

    Micro-Refineries are skid mounted modular crude oil distillation units which process couple wells production and are capable of producing a variety of finished products including naphtha (straight run gasoline), kerosene, diesel and fuel oil. Since it is modular, two or more units could be installed on a single site allowing the simultaneous processing of more than one type of crude oil; and one plant can still be in operation in the event one plant is down.

    •Capacity increase can be achieved with even limited capital investment.
    •System can be set up and put in operation within couple days after arrival at a site where the production is ongoing or storage tanks are in place. 
    •A single operator may restart the plant from a cold start and have the plant in full operation in less than two hours. 
    •Requires no water, steam, or instrument air. 
    •Fuel supply can be natural gas, naphtha, diesel fuel oil or a combination of these fuels.

     

     

     

     

    Super Critical Extraction

    De asphalting can be done using liquefied hydrocarbon gases. Under mild pressure hydrocarbon gases efficiently takes distillation residue from the capillary tubes of hybrid catalytic system.

    Gas can easily be recycled by decreasing pressure and carry all asphalts to desired storage area gasification unit.

     

     

    Gasification & Catalytic Reforming

     

    Heavy fractions entering the gasification unit are instantly converted into syngas.

    Our gasification unit reaches up to temperature of 13,900 °C and destroys all heavy fraction to clean syngas. Even coal or tar sand or any organic material can be converted to syngas.

    Syngas goes to catalytic reformer to produce gasoline, diesel, jet fuel or methanol

    Entire system can be containerized into modular units.

     

    It can easily be scaled up by adding more units to increase the refining capacity.

    Fully automatic system cleans itself and requires minimum manpower 

    Entire system can be containerized into modular units.

    It can easily be scaled up by adding more units to increase the refining capacity.

    More
  • Reservoir Modeling

    Reservoir Modeling

    The objective of geomodeling is to capture geology of the reservoir in a representative static model for dynamic simulation which also shows gross features or detailed characteristics and has capacity of making quantitative predictions.

    For an accurate simulation model, each and every step of geomodeling workflow is extremely important.

     

    Our geomodeling workflow is a process to integrate data from various sources, disciplines and scales in a consistent manner to estimate the reservoir properties.

    The construction of such a model can significantly increase the value of the data and enhance the decision making process. Ultimately, the value gained in enhanced reservoir model resolution, accuracy and reliability is leveraged to exploit reservoirs with fewer, better located wells and obtain optimized development scheme.

    We start building the model by using seismic structure and establishing a broad sequence stratigraphic framework from an initial investigation of the relevant data. The stratigraphic sequence is identified from the well log data and have a reasonably consistent seismic which defines number of zones. After fault and fracture integration into 3D model, porositypermeability and saturation models are completed to form geological model.

    More
  • Biogas Production

    Biogas Production

    DME (Di Methyl Ether) is a modern and safe source of energy which compares very favorably when compared with other energy sources in use or under consideration today.
    Recently DME started attracting more attention in the energy market worldwide as a new  CLEAN FUEL
    derived by chemical conversion of natural gas or coal. Many companies are interested in developing DME as a commercial fuel since 2000 and participated Japanese consortium for technical validation of a new advanced production technology as well as for feasibility study of establishing a DME chain from gas producing country to Asian markets.

    DME (Dimethyl Ether, CH3–O–CH3) is an LPG-like synthetic fuel that is produced through gasification of various renewable substances or fossil fuels. The synthetic gas is then catalyzed to produce DME. It is produced from natural gas but it can also be produced from other sources like biomass and coal. The production of DME is very similar to that of methanol: Natural gas at remote locations is the most economic feedstock for both alternative fuels. DME is a clean burning (completely soot less) synthetic fuel that can substitute for conventional diesel, liquefied petroleum gas (LPG) or be reformed into hydrogen for fuel cells. As a diesel fuel replacement it reduces NOx emissions 90%, meeting the 2007 diesel emission standards, and features high cetane. It can be transported as a pressurized liquid similar to LPG. Also, as mentioned earlier, DME can be economically produced from a number of feedstock: coal, natural gas, and biomass. Countries which are seeing an exponential increase in their energy demand are extremely interested in setting up DME plants and China has taken the lead in the same. China, in particular, because of its enormous coal reserves, is interested in the Coal to DME process. Oil and gas companies are focusing on DME as a way to efficiently use their natural gas resources. They want to utilize the natural gas produced by wells that are far from distribution infrastructure and are looking to convert the gas to product (liquid, fuel, chemical) close to the well site and transport that instead. This is where DME is being thought about in a big way.

    DME already has an environmentally clean background and good safety record as propellant in spray cans for the cosmetic industry. It has been used in a low pressure gaseous state as ignition improver of methanol. DME is a new fuel planned for introduction as a safe, environmentally benign energy source for fuel cells or diesel engines. DME can serve as a synthetic fuel that is to diesel what LPG is to gasoline. It is gaseous at ambient conditions but can be liquefied at moderate pressure. With a high cetane number, DME has very attractive characteristics as an alternative fuel for diesel engines. DME can be blended up to 20% with LPG and used for household cooking and heating, without any modifications to equipment or used as a replacement. DME can also be used as a clean burning substitute for diesel in transportation and as a clean fuel for power generation. DME would be particularly attractive for countries which have large coal reserves or forest produce. Just to give an example, it is possible to use black liquor, a residual product from production of paper pulp (from forest produce), as a feedstock for manufacturing DME.

    DME can be manufactured by dehydration of methanol but also by direct synthesis from synthesis gas. Synthesis gas can be produced from any carbon containing raw material. Currently, the most cost effective way to produce synthesis gas is by reforming natural gas. Assessments indicate that large-scale manufacture of DME from natural gas can be cost competitive with diesel fuel. The synthetic gas is then catalyzed to produce DME. It can be produced at lower energy use and GHG (greenhouse gas) emissions, especially when biomass is used as a feedstock, than other GTL or BTL fuels. In the coal route of DME manufacture, coal is first gasified to produce a syngas rich in CO and hydrogen. The syngas is then put through the water gas shift reaction (CO + H2O _ H2+ CO2) to maximize conversion in the synthesis reactor. Acid gases (H2S and CO2) and other impurities are removed from the syngas, which then moves to the synthesis reactor for production into DME. By-produced CO2, methanol and water are separated from the product DME in the distillation columns. Methanol is recycled to DME synthesis reactor to be converted into DME. Synthesis gas can also be produced from biomass, albeit at a higher cost than from natural gas. By using biomass as feedstock, the emissions of fossil CO2 can be considerably reduced.

    If there is a need for LPG for cooking and domestic (household heating and cooking) uses, then there is a ready market for DME. DME can be produced in Asia at a fairly consistent price as an LPG replacement and as a “clean cooking fuel”, without subjecting consumers to the volatility of LPG price swings (which follow petroleum prices). In China, facilities that make methanol from coal gasification are being converted to DME by adding a methanol dehydration step to the methanol plant. So, there is a market for clean cooking fuel and a price stability benefit for DME.

    Another way to view the potential for the DME market is the cost involved in taking conventional diesel technology and making “clean diesel” vehicles.  To meet the 2010 NOx and PM standards will require substantial additional vehicle costs for higher levels of in-cylinder pollutant control and for exhaust after treatment. One could nearly achieve this same emissions level with only a modest amount (or even perhaps none at all) of after treatment.  So, the net cost may be able the same for a DME vehicle and the consumer appeal could be far better.

     

    More
  • Oil and Gas E&P

    Oil and Gas E&P

    Our main objective and activities are to consult operating companies and acquire exploration, production rights of high potential concessions from various countries:

    • Acquire undeveloped oil fields in onshore and offshore areas
       
    • Acquire abandoned fields around the world for re-development
       
    • Develop and implement innovative oil and gas exploration, production and processing technologies

    With our highly experiences experts, we anticipate, identify, and resolve inquires and opportunities quickly and more accurately in an economic way.

    Today’s unstable and uncertain global business environment requires E&P companies or investment organizations to have faster decision cycles, streamlined data processing and satisfaction of cost effective objectives. Production of mature fields has already started to decline while the newly targeted fields and reservoirs impose more complexity, risk and difficulty for efficient and economical development. Decision-makers are required better understanding of the uncertainties that have higher impact on project economics. The bottlenecking critical capability for the management is to use the available data to derive realistic and reliable conclusions and decisions.

    In response to growing demand of energy, we have anticipated to perform reserve audits, exploration portfolio analyses, technical and commercial risk management.

    Holistic Value Generation Cycle

     

    The green assets and undeveloped fields ranking is based on the following factors:

    1. Reservoir characteristics, which can be evaluated from the surrounded exploratory wells and fields in addition to the regional knowledge which includes the effective porosity and permeability and type of carbonate rocks.
    2. Distance from the nearest production infrastructures such as pipe lines, which will help in reducing the development cost.
    3. Exploration potential, which represents the possibility to find additional discoveries.
    4. Available published technical data, which includes seismic coverage (2D & 3D), number and total depth of the drilled wells, types and quality of the open hole logs and the regional studies that were conducted either in-house or by consultants.
    5. Location of the concerned fields from the hydrocarbon migration pathways and availability of mature source rocks.
    6. Identify the potential stratigraphic plays that are expected to be encountered within the concession area in order to be including as additional exploratory target.
    7. Location of the evaluated fields from the main tectonic movements and their possible effect on the reservoir characters and trapping mechanism.
    8. Efficiency of the cap rocks in terms of thickness and their ability to prevent escape of the hydrocarbon.
    9. Depth of burial for the primary target reservoirs, which has a direct impact on the drilling cost in term of time required to reach the reservoir and to predict the type of hydrocarbon.
    10. Possible existence of production risks such as sour gas (the expected H2S present).
    11. If offshore, water depth since the shallow depths require high cost of artificial islands for drilling and production platforms.
    12. Define the volume and nature of work that required enhancing the exploration opportunities.
    13. Net pay thickness and oil saturation, which has a proportional relationship with the estimated reserves and the development plan.
    14. Expected reservoir producing mechanism in order to predict the different production scenarios and recoveries.
    15. Possible drilling problems such as loss of circulation, stuck pipes and shale caving which increase the drilling complexity and budget.

    More